ConocoPhillips (COP) 10-Q 4 Aug 09 2009 Q2 Quarterly report Financial data

Document Information

Document Information
	6 Months Ended Jun. 30, 2009 USD / shares
Document Information
Document Type	10-Q
Amendment Flag	false
Document Period End Date	2009-06-30

Entity Information

Entity Information (USD $)
	6 Months Ended Jun. 30, 2009
Entity Information
Entity Registrant Name	ConocoPhillips
Entity Central Index Key	0001163165
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float	$143,400,000,000
Entity Common Stock, Shares Outstanding	1,482,903,059

Consolidated Income Statement

Consolidated Income Statement (USD $)
In Millions, except Share data	3 Months Ended Jun. 30, 2009		3 Months Ended Jun. 30, 2008		6 Months Ended Jun. 30, 2009		6 Months Ended Jun. 30, 2008
Revenues and Other Income
Sales and other operating revenues	$35,448	[1]	$71,411	[1]	$66,189	[1]	$126,294	[1]
Equity in earnings of affiliates	1,076		1,812		1,491		3,171
Other income	106		130		230		440
Total Revenues and Other Income	36,630		73,353		67,910		129,905
Costs and Expenses
Purchased crude oil, natural gas and products	24,609		51,214		44,368		89,034
Production and operating expenses	2,573		3,111		5,118		5,802
Selling, general and administrative expenses	476		629		951		1,155
Exploration expenses	243		288		468		597
Depreciation, depletion and amortization	2,347		2,178		4,577		4,387
Impairments - Expropriated assets	51		0		51		0
Impairments - Other	0		19		3		25
Taxes other than income taxes	3,715	[1]	5,796	[1]	7,179	[1]	10,951	[1]
Accretion on discounted liabilities	108		96		212		200
Interest and debt expense	268		210		578		417
Foreign currency transaction (gains) losses	(142)		0		(11)		(43)
Total Costs and Expenses	34,248		63,541		63,494		112,525
Income before income taxes	2,382		9,812		4,416		17,380
Provision for income taxes	1,068		4,356		2,246		7,766
Net income	1,314		5,456		2,170		9,614
Less: net income attributable to noncontrolling interests	(16)		(17)		(32)		(36)
Net Income Attributable to ConocoPhillips	$1,298		$5,439		$2,138		$9,578
Net Income Attributable to ConocoPhillips Per Share of Common Stock (dollars)
Basic	0.87		3.54		1.44		6.18
Diluted	0.87		3.5		1.43		6.11
Dividends Paid Per Share of Common Stock (dollars)	0.47		0.47		0.94		0.94
Average Common Shares Outstanding (in thousands)
Basic	1,486,496		1,534,975		1,486,195		1,548,587
Diluted	1,495,700		1,555,447		1,495,474		1,568,867
[1]Includes excise taxes on petroleum products sales of $3,316 MM for the three months ended and $6,376 MM for the six months ended June 30, 2009 and $4,091 MM for the three months ended and $7,948 MM for the six months ended June 30, 2008.

Consolidated Balance Sheet

Consolidated Balance Sheet (USD $)
In Millions	Jun. 30, 2009	Dec. 31, 2008
Assets
Cash and cash equivalents	$888	$755
Accounts and notes receivable (net of allowance of $70 million in 2009 and $61 million in 2008)	10,747	10,892
Accounts and notes receivable - related parties	1,750	1,103
Inventories	6,181	5,095
Prepaid expenses and other current assets	3,508	2,998
Total Current Assets	23,074	20,843
Investments and long-term receivables	33,551	30,926
Loans and advances - related parties	2,038	1,973
Net properties, plants and equipment	86,246	83,947
Goodwill	3,715	3,778
Intangibles	835	846
Other assets	614	552
Total Assets	150,073	142,865
Liabilities
Accounts payable	13,197	12,852
Accounts payable-related parties	1,777	1,138
Short-term debt	1,438	370
Accrued income and other taxes	3,816	4,273
Employee benefit obligations	695	939
Other accruals	2,166	2,208
Total Current Liabilities	23,089	21,780
Long-term debt	28,926	27,085
Asset retirement obligations and accrued environmental costs	7,580	7,163
Joint venture acquisition obligation-related party	5,343	5,669
Deferred income taxes	18,136	18,167
Employee benefit obligations	4,178	4,127
Other liabilities and deferred credits	2,814	2,609
Total Liabilities	90,066	86,600
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value), Issued (2009 - 1,731,058,293 shares; 2008 - 1,729,264,859 shares) Par value	17	17
Capital in excess of par	43,514	43,396
Grantor trusts (at cost: 2009 - 39,808,419 shares; 2008 - 40,739,129 shares)	(688)	(702)
Treasury stock (at cost: 2009 and 2008 - 208,346,815 shares)	(16,211)	(16,211)
Accumulated other comprehensive income (loss)	998	(1,875)
Unearned employee compensation	(89)	(102)
Retained earnings	31,388	30,642
Total Common Stockholders' Equity	58,929	55,165
Noncontrolling interests	1,078	1,100
Total Equity	60,007	56,265
Total Liabilities and Equity	$150,073	$142,865

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parentheticals) (USD $)
In Millions, except Share data, unless otherwise specified	Jun. 30, 2009	Dec. 31, 2008
Consolidated Balance Sheet (Parentheticals)
Allowance for Doubtful Accounts	$70	$61
Common Stock Shares Authorized	2,500,000,000	2,500,000,000
Common Stock, Par or Stated Value Per Share (dollars)	0.01	0.01
Common Stock Shares Issued	1,731,058,293	1,729,264,859
Grantor Trust Shares	39,808,419	40,739,129
Treasury Stock Shares	208,346,815	208,346,815

Consolidated Statement of Cash

Consolidated Statement of Cash Flows (USD $)
In Millions	6 Months Ended Jun. 30, 2009	6 Months Ended Jun. 30, 2008
Cash Flows From Operating Activities
Net income	$2,170	$9,614
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	4,577	4,387
Impairments	54	25
Dry hole costs and leasehold impairments	238	281
Accretion on discounted liabilities	212	200
Deferred taxes	(596)	11
Undistributed equity earnings	(1,092)	(1,988)
Gain on asset dispositions	(36)	(213)
Other	175	(117)
Working capital adjustments
Decrease (increase) in accounts and notes receivable	65	(3,625)
Decrease (increase) in inventories	(973)	(2,537)
Decrease (increase) in prepaid expenses and other current assets	(435)	(2,349)
Increase (decrease) in accounts payable	1,020	5,481
Increase (decrease) in taxes and other accruals	(927)	2,851
Net Cash Provided by Operating Activities	4,452	12,021
Cash Flows From Investing Activities
Capital expenditures and investments	(5,578)	(6,720)
Proceeds from asset dispositions	232	441
Long-term advances/loans-related parties	(121)	(154)
Collection of advances/loans-related parties	36	4
Other	(77)	7
Net Cash Used in Investing Activities	(5,508)	(6,422)
Cash Flows From Financing Activities
Issuance of debt	9,029	2,065
Repayment of debt	(6,109)	(1,841)
Issuance of company common stock	(21)	185
Repurchase of company common stock	0	(5,008)
Dividends paid on company common stock	(1,393)	(1,449)
Other	(406)	(240)
Net Cash Provided by (Used in) Financing Activities	1,100	(6,288)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	89	20
Net Change in Cash and Cash Equivalents	133	(669)
Cash and cash equivalents at beginning of period	755	1,456
Cash and Cash Equivalents at End of Period	$888	$787

Interim Financial Information

Interim Financial Information
	6 Months Ended Jun. 30, 2009 USD / shares
Interim Financial Information
Note 1 - Interim Financial Information	Note 1Interim Financial Information The interim-period financial information presented in the financial statements included in this report is unaudited and includes all known accruals and adjustments, in the opinion of management, necessary for a fair presentation of the consolidated financial position of ConocoPhillips and its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature. To enhance your understanding of these interim financial statements, see the consolidated financial statements and notes included in our 2008 Annual Report on Form 10-K.

Changes in Accounting Principle

Changes in Accounting Principles
	6 Months Ended Jun. 30, 2009 USD / shares
Changes in Accounting Principles
Note 2 - Changes in Accounting Principles	Note 2Changes in Accounting Principles SFAS No. 165 Effective April 1, 2009, we adopted Financial Accounting Standards Board (FASB) Statement of Financial Accounting Standards (SFAS) No. 165, Subsequent Events. This Statement establishes the accounting for, and disclosure of, material events that occur after the balance sheet date, but before the financial statements are issued. In general, these events will be recognized if the condition existed at the date of the balance sheet, and will not be recognized if the condition did not exist at the balance sheet date. Disclosure is required for nonrecognized events if required to keep the financial statements from being misleading. The guidance in this Statement is very similar to current guidance provided in auditing literature and, therefore, will not result in significant changes in practice. Subsequent events have been evaluated through the date our interim financial statements were issuedthe filing time and date of our second-quarter 2009 Quarterly Report on Form 10-Q. SFAS No. 141 (Revised) In December 2007, the FASB issued SFAS No. 141 (Revised), Business Combinations (SFAS No. 141(R)), which was subsequently amended by FASB Staff Position (FSP) FAS 141(R)-1 in April 2009. This Statement applies prospectively to all transactions in which an entity obtains control of one or more other businesses on or after January 1, 2009. In general, SFAS No. 141(R) requires the acquiring entity in a business combination to recognize the fair value of all assets acquired and liabilities assumed in the transaction; establishes the acquisition date as the fair value measurement point; and modifies disclosure requirements. It also modifies the accounting treatment for transaction costs, in-process research and development, restructuring costs, changes in deferred tax asset valuation allowances as a result of a business combination, and changes in income tax uncertainties after the acquisition date. Additionally, effective January 1, 2009, accounting for changes in valuation allowances for acquired deferred tax assets and the resolution of uncertain tax positions for prior business combinations impact tax expense instead of goodwill. SFAS No. 160 Effective January 1, 2009, we implemented SFAS No. 160, Noncontrolling Interests in Consolidated Financial Statementsan amendment of ARB No. 51, which requires noncontrolling interests, previously called minority interests, to be presented as a separate item in the equity section of the consolidated balance sheet. It also requires the amount of consolidated net income attributable to noncontrolling interests to be clearly presented on the face of the consolidated income statement. Additionally, this Statement clarifies that changes in a parents ownership interest in a subsidiary that do not result in deconsolidation are equity transactions, and that deconsolidation of a subsidiary requires gain or loss recognition in net income based on the fair value on the deconsolidation date. This Statement was applied prospectively with the exception of presentation and disclosure requirements, which were applied retrospectively for all periods pre

Variable Interest Entities

Variable Interest Entities (VIEs)
	6 Months Ended Jun. 30, 2009 USD / shares
Variable Interest Entities (VIEs)
Note 3 - Variable Interest Entities (VIEs)	Note 3Variable Interest Entities (VIEs) We hold significant variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on these VIEs follows. We own a 24 percent interest in West2East Pipeline LLC, a company holding a 100 percent interest in Rockies Express Pipeline LLC, operated by Kinder Morgan Energy Partners, L.P. Rockies Express is constructing a natural gas pipeline from Colorado to Ohio. West2East is a VIE because a third party has a 49 percent voting interest through the end of the construction of the pipeline, but has no ownership interest. This third party was originally involved in the project, but exited and retained its voting interest to ensure project completion. We have no voting interest during the construction phase, but once the pipeline has been completed, our ownership will increase to 25 percent with a voting interest of 25 percent. Additionally, we have contracted for approximately 22 percent of the pipeline capacity for a 10-year period once the pipeline becomes operational. Construction commenced on the pipeline in 2006. The operator anticipates construction completion in late 2009 and estimates total construction costs of approximately $6.7 billion. Our portion is expected to be funded by a combination of equity contributions and a guarantee of debt incurred by Rockies Express. Given our 24percent ownership and the fact expected returns are shared among the equity holders in proportion to ownership, we are not the primary beneficiary. We use the equity method of accounting for our investment. At June 30, 2009, the book value of our investment in West2East was $437million. Construction cost estimates have increased significantly from original projections, and additional increases or other changes related to the investment may impact whether an other-than-temporary impairment of our equity investment in West2East is required. We have a 30 percent ownership interest with a 50 percent governance interest in the OOO Naryanmarneftegaz (NMNG) joint venture to develop resources in the Timan-Pechora province of Russia. The NMNG joint venture is a VIE because we and a related party, OAO LUKOIL, have disproportionate interests. When related parties are involved in a VIE, reasonable judgment should take into account the relevant facts and circumstances for the determination of the primary beneficiary. The activities of NMNG are more closely aligned with LUKOIL because they share Russia as a home country, and LUKOIL conducts extensive exploration activities in the same province. Additionally, there are no financial guarantees given by LUKOIL or us, and LUKOIL owns 70 percent, versus our 30 percent direct interest. As a result, we have determined we are not the primary beneficiary of NMNG, and we use the equity method of accounting for this investment. The funding of NMNG has been provided with equity contributions, primarily for the development of the Yuzhno Khylchuyu (YK) Field. Initial production from YK was achieved in June 2008. At June 30, 2009, the book value of our investment in the venture was $2,061 million. Production from the NM

Inventories

Inventories
	6 Months Ended Jun. 30, 2009 USD / shares
Inventories
Note 4 - Inventories	Note 4Inventories Inventories consisted of the following: Millions of Dollars June 30 December 31 2009 2008 Crude oil and petroleum products $ 5,231 4,232 Materials, supplies and other 950 863 $ 6,181 5,095 Inventories valued on the last-in, first-out (LIFO) basis totaled $5,042 million and $3,939million at June 30, 2009, and December31, 2008, respectively. The remaining inventories are valued under various methods, including first-in, first-out and weighted average. The excess of current replacement cost over LIFO cost of inventories amounted to $4,873 million and $1,959 million at June 30, 2009, and December31, 2008, respectively.

Assets Held for Sale

Assets Held for Sale
	6 Months Ended Jun. 30, 2009 USD / shares
Assets Held for Sale
Note 5 - Assets Held for Sale	Note 5Assets Held for Sale In June 2009, we signed an agreement to sell our remaining interest in the Keystone Pipeline to TransCanada Corporation. Subject to final regulatory approvals, the transaction is expected to close in the third quarter of this year. As a result, at June 30, 2009, we reclassified $505 million from Investments and long-term receivables to Prepaid expenses and other current assets on our consolidated balance sheet, and recorded a noncash impairment of $59 million before-tax, including associated cumulative foreign currency translation losses of $36 million and allocable goodwill of $61million. This impairment, which is based on a Level 1 measurement in the fair value hierarchy, was reflected in Equity in earnings of affiliates in our consolidated income statement

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables
	6 Months Ended Jun. 30, 2009 USD / shares
Investments, Loans and Long-Term Receivables
Note 6 - Investments, Loans and Long-Term Receivables	Note 6Investments, Loans and Long-Term Receivables LUKOIL Our ownership interest in LUKOIL was 20 percent at June 30, 2009, based on 851 million shares authorized and issued. For financial reporting under U.S. generally accepted accounting principles (GAAP), treasury shares held by LUKOIL are not considered outstanding for determining our equity method ownership interest in LUKOIL. Our ownership interest, based on estimated shares outstanding, was 20.09 percent at June 30, 2009. At June 30, 2009, the book value of our ordinary share investment in LUKOIL was $5,913 million. Our 20percent share of the net assets of LUKOIL was estimated to be $10,471 million. A majority of this negative basis difference of $4,558 million is being amortized on a straight-line basis over a 22-year useful life as an increase to equity earnings. On June 30, 2009, the closing price of LUKOIL shares on the London Stock Exchange was $44.37 per share, making the total market value of our LUKOIL investment $7,548 million. Because LUKOILs accounting cycle close and preparation of U.S. GAAP financial statements occur subsequent to our reporting deadline, our equity earnings are estimated based on current market indicators, publicly available LUKOIL information and other objective data. Once the difference between actual and estimated results is known, an adjustment is recorded. Net income attributable to ConocoPhillips for the second quarter of 2009 included a $192 million positive alignment of our first-quarter estimate of LUKOILs results to LUKOILs reported results. Loans to Related Parties As part of our normal ongoing business operations and consistent with industry practice, we invest and enter into numerous agreements with other parties to pursue business opportunities, which share costs and apportion risks among the parties as governed by the agreements. Included in such activity are loans made to certain affiliated companies. Significant loans to affiliated companies at June 30, 2009, included the following: $737 million in loan financing to Freeport LNG Development, L.P. for the construction of an LNG receiving terminal, which became operational in June 2008. In August 2008, when the loan was converted from a construction loan to a term loan, it consisted of $650 million in loan financing and $124 million of accrued interest. Freeport began making repayments in September 2008. $271 million at June 2009 exchange rates, excluding accrued interest, in loan financing to Varandey Terminal Company associated with the costs of a terminal expansion. Terminal expansion was completed in June 2008, and although repayments are not required to start until May 2010, beginning in the second half of 2008 and through June 30, 2009, Varandey used available cash to pay $40million of interest. The outstanding accrued interest at June 30, 2009, was $23 million at June 2009 exchange rates. $956 million of project financing and an additional $82 million of accrued interest to Qatargas 3, an integrated project to produce and liquefy natural gas from Qatars North Field. Our maximum exposure to this financing structure is $1.2 billion.

Properties, Plants and Equipmen

Properties, Plants and Equipment
	6 Months Ended Jun. 30, 2009 USD / shares
Properties, Plants and Equipment
Note 7 - Properties, Plants and Equipment	Note 7Properties, Plants and Equipment Our investment in properties, plants and equipment (PPE), with accumulated depreciation, depletion and amortization (Accum. DDA), was: Millions of Dollars June 30, 2009 December 31, 2008 Gross PPE Accum. DDA Net PPE Gross PPE Accum. DDA Net PPE Exploration and Production (EP) $ 108,846 40,404 68,442 102,591 35,375 67,216 Midstream 122 71 51 120 70 50 Refining and Marketing (RM) 22,514 6,410 16,104 21,116 5,962 15,154 LUKOIL Investment - - - - - - Chemicals - - - - - - Emerging Businesses 1,191 290 901 1,056 293 763 Corporate and Other 1,579 831 748 1,561 797 764 $ 134,252 48,006 86,246 126,444 42,497 83,947 Suspended Wells Our capitalized cost of suspended wells at June 30, 2009, was $861 million, an increase of $201million from $660 million at year-end 2008. For the category of exploratory well costs capitalized for a period greater than one year as of December 31, 2008, $13million was charged to dry hole expense during the first six months of2009.

Impairments

Impairments
	6 Months Ended Jun. 30, 2009 USD / shares
Impairments
Note 8 - Impairments	Note 8Impairments Expropriated Assets In April 2008, we initiated arbitration before the World Banks International Centre for Settlement of Investment Disputes (ICSID) against The Republic of Ecuador and PetroEcuador (collectively, Respondents) as a result of the governments confiscatory fiscal measures enacted through the Windfall Profits Tax Law, implemented in 2006 and 2007, and the government-mandated renegotiation of our production sharing contracts into service agreements with inferior fiscal and legal terms. In February 2009, PetroEcuador issued notices to seize oil production from Blocks 7 and 21 as part of Ecuadors efforts to collect prior alleged unpaid taxes owed under the disputed Windfall Profits Tax Law. In March 2009, the ICSID Tribunal granted a temporary restraining order that commanded the Respondents to refrain from any conduct that aggravates the dispute between the parties or alters the status quo. However, the Respondents ignored the order, confiscated approximately 470,000 net barrels of crude oil and attempted to sell it through a public auction. In the second quarter of 2009, the ICSID Tribunal heard our motion for provisional measures and issued a second decision that ordered the Respondents to refrain from confiscating future production until a final decision has been rendered in the pending arbitration. The Respondents also ignored this decision by the Tribunal, continued to confiscate our crude oil production and sold the illegally seized crude oil to PetroEcuador at a 50 percent discount off the market value. As a result, our assets in Ecuador have been effectively expropriated. Accordingly, in the second quarter of 2009, we recorded a noncash charge of $51million before- and after-tax related to the full impairment of our exploration and production investments in Ecuador.

Debt

Debt
	6 Months Ended Jun. 30, 2009 USD / shares
Debt
Note 9 - Debt	Note 9Debt In February 2009, we issued $1.5 billion of 4.75% Notes due 2014, $2.25 billion of 5.75% Notes due 2019, and $2.25 billion of 6.50% Notes due 2039. In addition, in May 2009, we issued $1.5 billion of 4.60% Notes due 2015, $1.0 billion of 6.00% Notes due 2020 and $500 million of 6.50% Notes due 2039. The proceeds from the notes were primarily used to reduce outstanding commercial paper balances and for general corporate purposes. During the first six months of 2009, we used proceeds from the issuance of commercial paper to redeem $284million of 6.375% Notes and $950 million of Floating Rate Notes upon their maturity. At June 30, 2009, we had a $7.35 billion revolving credit facility, which expires in September 2012. The facility may be used as direct bank borrowings, as support for the ConocoPhillips $5.6 billion commercial paper program, as support for the ConocoPhillips Qatar Funding Ltd. $1.5 billion commercial paper program, as support for issuances of letters of credit totaling up to $750 million, or as support for up to $250 million of commercial paper issued by TransCanada Keystone Pipeline LP, a Keystone Pipeline joint venture entity. At both June 30, 2009, and December 31, 2008, we had no outstanding borrowings under the credit facility, but $40million in letters of credit had been issued. Under both ConocoPhillips commercial paper programs, $2,211 million of commercial paper was outstanding at June 30, 2009, compared with $6,933 million at December 31, 2008. Since we had $2,211 million of commercial paper outstanding, had issued $40 million of letters of credit and had up to a $250 million guarantee on commercial paper issued by Keystone, we had access to $4.8 billion in borrowing capacity under our revolving credit facility at June 30, 2009. Also at June 30, 2009, we classified $2,278 million of short-term debt as long-term debt, based on our ability and intent to refinance the obligation on a long-term basis under our revolving credit facility. In July 2009, we arranged a new $500 million credit facility, which expires in July 2012, bringing our total borrowing capacity under our revolving credit facilities to $7.85 billion.

Joint Venture Acquisition Oblig

Joint Venture Acquisition Obligation
	6 Months Ended Jun. 30, 2009 USD / shares
Joint Venture Acquisition Obligation
Note10 - Joint Venture Acquisition Obligation	Note 10Joint Venture Acquisition Obligation We are obligated to contribute $7.5 billion, plus interest, over a 10-year period, beginning in 2007, to FCCL Partnership. Quarterly principal and interest payments of $237 million began in the second quarter of 2007 and will continue until the balance is paid. Of the principal obligation amount, approximately $642million was short-term and was included in the Accounts payablerelated parties line on our June 30, 2009, consolidated balance sheet. The principal portion of these payments, which totaled $309 million in the first six months of 2009, are included in the Other line in the financing activities section of our consolidated statement of cash flows. Interest accrues at a fixed annual rate of 5.3 percent on the unpaid principal balance. Fifty percent of the quarterly interest payment is reflected as a capital contribution and is included in the Capital expenditures and investments line on our consolidated statement of cash flows.

Guarantees

Guarantees
	6 Months Ended Jun. 30, 2009 USD / shares
Guarantees
Note 11 - Guarantees	Note 11Guarantees At June 30, 2009, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability either because the guarantees were issued prior to December31, 2002, or because the fair value of the obligation is immaterial. In addition, unless otherwise stated we are not currently performing with any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence. Construction Completion Guarantees In December 2005, we issued a construction completion guarantee for 30percent of the $4billion in loan facilities of Qatargas 3, which will be used to construct an LNG train in Qatar. Of the $4billion in loan facilities, we committed to provide $1.2billion. The maximum potential amount of future payments to third-party lenders under the guarantee is estimated to be $850 million, which could become payable if the full debt financing is utilized and completion of the Qatargas 3 project is not achieved. The project financing will be nonrecourse to ConocoPhillips upon certified completion, expected in 2011. At June 30, 2009, the carrying value of the guarantee to third-party lenders was $11million. Guarantees of Joint Venture Debt In June 2006, we issued a guarantee for 24 percent of $2 billion in credit facilities of Rockies Express Pipeline LLC, operated by Kinder Morgan Energy Partners, L.P. At June 30, 2009, Rockies Express had $1,883 million outstanding under the credit facilities, with our 24 percent guarantee equaling $452million. The maximum potential amount of future payments to third-party lenders under the guarantee is estimated to be $480million, which could become payable if the credit facilities are fully utilized and Rockies Express fails to meet its obligations under the credit agreement. In addition, we also have a guarantee for 24 percent of $600 million of Floating Rate Notes due in August 2009 issued by Rockies Express. The operator anticipates construction completion in late 2009. Refinancing of the $2 billion credit facility is expected to take place at that time, making the debt nonrecourse to ConocoPhillips. At June 30, 2009, the total carrying value of these guarantees to third-party lenders was $12 million. In December 2007, we acquired a 50 percent equity interest in four Keystone Pipeline entities (Keystone) to create a joint venture with TransCanada Corporation. Keystone is constructing a crude oil pipeline originating in Alberta with delivery points in Illinois and Oklahoma. In December 2008, we provided a guarantee of up to $250 million of balances outstanding under a commercial paper program. This program was established by Keystone to provide funding for a portion of its construction costs attributable to our ownership interest in the project. Payment under the guarantee would be due in the event Keystone failed to repay principal and interest, wh

Contingencies and Commitments

Contingencies and Commitments
	6 Months Ended Jun. 30, 2009 USD / shares
Contingencies and Commitments
Note 12 - Contingencies and Commitments	Note 12Contingencies and Commitments In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. In the case of income-tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes. Environmental We are subject to federal, state and local environmental laws and regulations. These may result in obligations to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various sites. When we prepare our consolidated financial statements, we record accruals for environmental liabilities based on managements best estimates, using all information available at the time. We measure estimates and base liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies cleanup experience, and data released by the U.S. Environmental Protection Agency (EPA) or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable. Although liability of those potentially responsible for environmental remediation costs is generally joint and several for federal sites and frequently so for state sites, we are usually only one of many companies cited at a particular site. Due to the joint and several liabilities, we could be responsible for all c

Financial Instruments and Deriv

Financial Instruments and Derivative Contracts
	6 Months Ended Jun. 30, 2009 USD / shares
Financial Instruments and Derivative Contracts
Note 13 - Financial Instruments and Derivative Contracts	Note 13Financial Instruments and Derivative Contracts Derivative Instruments We use financial and commodity-based derivative contracts to manage exposures to fluctuations in foreign currency exchange rates, commodity prices and interest rates, or to exploit market opportunities. Since we are not currently using hedge accounting, all gains and losses, realized or unrealized, from derivative contracts have been recognized in the consolidated income statement. Gains and losses from derivative contracts held for trading not directly related to our physical business, whether realized or unrealized, have been reported net in other income. Purchase and sales contracts for commodities that are readily convertible to cash (e.g., crude oil, natural gas and gasoline) are recorded on the balance sheet as derivatives unless the contracts are for quantities we expect to use or sell over a reasonable period in the normal course of business (i.e., contracts eligible for the normal purchases and normal sales exception). We record most of our contracts to buy or sell natural gas as derivatives, but we do apply the normal purchases and normal sales exception to certain long-term contracts to sell our natural gas production. We generally apply this normal purchases and normal sales exception to eligible crude oil and refined product commodity purchase and sales contracts; however, we may elect not to apply this exception (e.g., when another derivative instrument will be used to mitigate the risk of the purchase or sale contract but hedge accounting will not be applied, in which case both the purchase or sales contract and the derivative contract mitigating the resulting risk will be recorded on the balance sheet at fair value). We value our exchange-cleared derivatives using closing prices provided by the exchange as of the balance sheet date, and these are classified as Level 1 in the fair value hierarchy. Over-the-counter (OTC) financial swaps and physical commodity forward purchase and sale contracts are generally valued using quotations provided by brokers and price index developers such as Platts and Oil Price Information Service. These quotes are corroborated with market data and are classified as Level 2. In certain less liquid markets or for longer-term contracts, forward prices are not as readily available. In these circumstances, OTC swaps and physical commodity purchase and sale contracts are valued using internally developed methodologies that consider historical relationships among various commodities that result in managements best estimate of fair value. These contracts are classified as Level 3. Exchange-cleared financial options are valued using exchange closing prices and are classified as Level 1. Financial OTC and physical commodity options are valued using industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines whether the options are classified as Lev

Comprehensive Income

Comprehensive Income
	6 Months Ended Jun. 30, 2009 USD / shares
Comprehensive Income
Note 14 - Comprehensive Income	Note 14Comprehensive Income ConocoPhillips comprehensive income was as follows: Millions of Dollars Three Months Ended June 30 Six Months Ended June 30 2009 2008 2009 2008 Net income $ 1,314 5,456 2,170 9,614 After-tax changes in: Defined benefit pension plans Net prior service cost 3 (14 ) 6 (10 ) Net actuarial loss 33 (2 ) 67 7 Nonsponsored plans (1 ) 2 (2 ) 4 Foreign currency translation adjustments 3,079 178 2,801 (257 ) Hedging activities 2 2 1 - Comprehensive income 4,430 5,622 5,043 9,358 Less: comprehensive income attributable to noncontrolling interests (16 ) (17 ) (32 ) (36 ) Comprehensive income attributable to ConocoPhillips $ 4,414 5,605 5,011 9,322 Accumulated other comprehensive income (loss) in the equity section of the balance sheet included: Millions of Dollars June 30 2009 December 31 2008 Defined benefit pension plans $ (1,363 ) (1,434 ) Foreign currency translation adjustments 2,370 (431 ) Deferred net hedging loss (9 ) (10 ) Accumulated other comprehensive income (loss) $ 998 (1,875 ) None of the items within accumulated other comprehensive income (loss) relate to noncontrolling interests.

Cash Flow Information

Cash Flow Information
	6 Months Ended Jun. 30, 2009 USD / shares
Cash Flow Information
Note 15 - Cash Flow Information	Note 15Cash Flow Information Millions of Dollars Six Months Ended June 30 2009 2008 Cash Payments Interest $ 416 398 Income taxes 3,271 6,405

Employee Benefit Plans

Employee Benefit Plans
	6 Months Ended Jun. 30, 2009 USD / shares
Employee Benefit Plans
Note 16 - Employee Benefit Plans	Note 16Employee Benefit Plans Pension and Postretirement Plans Millions of Dollars Pension Benefits Other Benefits Components of Net Periodic Benefit Cost 2009 2008 2009 2008 U.S. Intl. U.S. Intl. Three Months Ended June 30 Service cost $ 49 18 47 24 2 4 Interest cost 70 35 62 46 11 16 Expected return on plan assets (46 ) (30 ) (56 ) (45 ) - - Amortization of prior service cost 2 - 2 - 2 2 Recognized net actuarial (gain) loss 46 9 17 3 (3 ) (6 ) Net periodic benefit costs $ 121 32 72 28 12 16 Six Months Ended June 30 Service cost $ 97 38 94 47 4 7 Interest cost 139 68 124 90 23 28 Expected return on plan assets (92 ) (59 ) (112 ) (89 ) - - Amortization of prior service cost 5 - 4 - 4 5 Recognized net actuarial (gain) loss 93 17 33 6 (7 ) (10 ) Net periodic benefit costs $ 242 64 143 54 24 30 During the first six months of 2009, we contributed $160 million to our domestic benefit plans and $70million to our international benefit plans. We currently expect to make additional contributions of approximately $590million to our domestic benefit plans and $70 million to our international benefit plans for totals of $750million and $140 million, respectively, in 2009. Severance Accrual As a result of the current business environments impact on our operating and capital plans, a reduction in our overall employee work force is occurring during 2009. Various business units and staff groups recorded accruals in the fourth quarter of 2008 for severance and related employee benefits totaling $162 million. The following table summarizes our severance accrual activity: Millions of Dollars June 30 2009 December 31 2008 Beginning balance $ 162 - Accruals 5 162 Benefit payments (66 ) - Ending balance $ 101 162 The remaining balance at June 30, 2009, of $101 million is classified as short-term.

Related Party Transactions

Related Party Transactions
	6 Months Ended Jun. 30, 2009 USD / shares
Related Party Transactions
Note 17 - Related Party Transactions	Note 17Related Party Transactions Significant transactions with related parties were: Millions of Dollars Three Months Ended June 30 Six Months Ended June 30 2009 2008 2009 2008 Operating revenues (a) $ 1,892 4,001 3,365 7,172 Purchases (b) 3,168 5,693 5,650 10,092 Operating expenses and selling, general and administrative expenses (c) 71 127 157 243 Net interest expense (d) 20 19 39 40 (a) We sold natural gas to DCP Midstream, LLC and crude oil to the Malaysian Refining Company Sdn. Bhd. (MRC), among others, for processing and marketing. Natural gas liquids, solvents and petrochemical feedstocks were sold to Chevron Phillips Chemical Company LLC (CPChem), gas oil and hydrogen feedstocks were sold to Excel Paralubes and refined products were sold primarily to CFJProperties and LUKOIL. Natural gas, crude oil, blendstock and other intermediate products were sold to WRB Refining LLC. In addition, we charged several of our affiliates including CPChem and Merey Sweeny, L.P. (MSLP) for the use of common facilities, such as steam generators, waste and water treaters, and warehouse facilities. (b) We purchased refined products from WRB Refining. We purchased natural gas and natural gas liquids from DCP Midstream and CPChem for use in our refinery processes and other feedstocks from various affiliates. We purchased crude oil from LUKOIL and refined products from MRC. We also paid fees to various pipeline equity companies for transporting finished refined products and natural gas, as well as a price upgrade to MSLP for heavy crude processing. We purchased base oils and fuel products from Excel Paralubes for use in our refinery and specialty businesses. (c) We paid processing fees to various affiliates. Additionally, we paid crude oil transportation fees to pipeline equity companies. (d) We paid and/or received interest to/from various affiliates, including FCCL Partnership. See Note 6Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures and Related

Segment Disclosures and Related Information
	6 Months Ended Jun. 30, 2009 USD / shares
Segment Disclosures and Related Information
Note 18 - Segment Disclosures and Related Information	Note 18Segment Disclosures and Related Information We have organized our reporting structure based on the grouping of similar products and services, resulting in six operating segments: 1) EPThis segment primarily explores for, produces, transports and markets crude oil, natural gas and natural gas liquids on a worldwide basis. 2) MidstreamThis segment gathers, processes and markets natural gas produced by ConocoPhillips and others, and fractionates and markets natural gas liquids, predominantly in the United States and Trinidad. The Midstream segment primarily consists of our 50 percent equity investment in DCP Midstream, LLC. 3) RMThis segment purchases, refines, markets and transports crude oil and petroleum products, mainly in the United States, Europe and Asia. 4) LUKOIL InvestmentThis segment represents our investment in the ordinary shares of OAO LUKOIL, an international, integrated oil and gas company headquartered in Russia. At June 30, 2009, our ownership interest was 20 percent based on issued shares, and 20.09 percent based on estimated shares outstanding. 5) ChemicalsThis segment manufactures and markets petrochemicals and plastics on a worldwide basis. The Chemicals segment consists of our 50percent equity investment in Chevron Phillips Chemical Company LLC. 6) Emerging BusinessesThis segment represents our investment in new technologies or businesses outside our normal scope of operations. Corporate and Other includes general corporate overhead, most interest expense and various other corporate activities. Corporate assets include all cash and cash equivalents. We evaluate performance and allocate resources based on net income attributable to ConocoPhillips. Intersegment sales are at prices that approximate market. Analysis of Results by Operating Segment Millions of Dollars Three Months Ended June 30 Six Months Ended June 30 2009 2008 2009 2008 Sales and Other Operating Revenues EP United States $ 5,397 15,964 11,493 27,511 International 5,048 8,471 11,699 16,912 Intersegment eliminationsU.S. (1,187 ) (2,525 ) (2,046 ) (4,637 ) Intersegment eliminationsinternational (1,397 ) (3,550 ) (2,785 ) (5,847 ) EP 7,861 18,360 18,361 33,939 Midstream Total sales 973 2,100 1,895 3,742 Intersegment eliminations (53 ) (30 ) (101 ) (119 ) Midstream 920 2,070 1,794 3,623 RM United States 18,415 37,250 31,416 64,211 International 8,368 13,969 14,832 24,895 Intersegment eliminationsU.S. (140 ) (285 ) (257 ) (504 ) Intersegment eliminationsinternational (12 ) (13 ) (21 ) (20 )

Income Taxes

Income Taxes
	6 Months Ended Jun. 30, 2009 USD / shares
Income Taxes
Note 19 - Income Taxes	Note 19Income Taxes Our effective tax rate for the second quarter and first six months of 2009 was 45 percent and 51 percent, respectively, compared with 44 percent and 45 percent for the same two periods of 2008. The change in the effective tax rate for the first six months of 2009, compared with the same period of 2008, was primarily due to a higher proportion of income in higher tax jurisdictions in 2009. The effective tax rate in excess of the domestic federal statutory rate of 35percent was primarily due to foreign taxes.

New Accounting Standards

New Accounting Standards
	6 Months Ended Jun. 30, 2009 USD / shares
New Accounting Standards
Note 20 - New Accounting Standards	Note 20New Accounting Standards In June 2009, the FASB issued SFAS No. 166, Accounting for Transfers of Financial Assets, an amendment of FASB Statement No. 140. This Statement removes the concept of a qualifying special purpose entity (SPE) from SFAS No. 140 and the exception for qualifying SPEs from the consolidation guidance of FASB Interpretation No. 46(R), Consolidation of Variable Interest Entities (FIN 46(R)). Additionally, the Statement clarifies the requirements for financial asset transfers eligible for sale accounting. This Statement is effective January 1, 2010, and we do not expect any significant impact to our consolidated financial statements. Also in June 2009, the FASB issued SFAS No. 167, Amendments to FASB Interpretation No. 46(R), which amends FIN 46(R) to address the effects of the elimination of the qualifying SPE concept in SFAS No. 166, and other concerns about the application of key provisions of FIN 46(R). More specifically, SFAS No. 167 requires a qualitative rather than a quantitative approach to determine the primary beneficiary of a VIE, it amends certain guidance pertaining to the determination of the primary beneficiary when related parties are involved, and it amends certain guidance for determining whether an entity is a VIE. Additionally, this Statement requires continuous assessments of whether an enterprise is the primary beneficiary of a VIE. This Statement is effective January 1, 2010. We are currently evaluating the impact on our consolidated financial statements. The FASB issued SFAS No. 168, The FASB Standards Codification and the Hierarchy of Generally Accepted Accounting Principlesa replacement of FASB Statement 162, in late June 2009. The FASB Accounting Standards Codification will become the source of authoritative U.S. generally accepted accounting principles (GAAP) and will supersede all then-existing non-SEC accounting and reporting standards on the effective date, September 15, 2009. The Codification will not change GAAP, but consolidates it into a logical and consistent structure. We will be required to revise our references to GAAP in our financial statements beginning with the third quarter of 2009. In December 2008, the FASB issued FSP FAS 132(R)-1, Employers Disclosures about Postretirement Benefit Plan Assets, to improve the transparency associated with disclosures about the plan assets of a defined benefit pension or other postretirement plan. This FSP requires the disclosure of each major asset category at fair value using the fair value hierarchy in SFAS No. 157, Fair Value Measurements. This FSP is effective for annual financial statements beginning with the 2009 fiscal year, but will not impact our consolidated financial statements, other than requiring additional disclosures.

Supplementary Information - Con

Supplementary Information - Condensed Consolidating Financial Information
	6 Months Ended Jun. 30, 2009 USD / shares
Condensed Consolidating Financial Information
Supplementary Information - Condensed Consolidating Financial Information	Supplementary InformationCondensed Consolidating Financial Information We have various cross guarantees among ConocoPhillips, ConocoPhillips Company, ConocoPhillips Australia Funding Company, ConocoPhillips Canada Funding Company I, and ConocoPhillips Canada Funding Company II, with respect to publicly held debt securities. ConocoPhillips Company is wholly owned by ConocoPhillips. ConocoPhillips Australia Funding Company is an indirect, wholly owned subsidiary of ConocoPhillips Company. ConocoPhillips Canada Funding Company I and ConocoPhillips Canada Funding Company II are indirect, wholly owned subsidiaries of ConocoPhillips. ConocoPhillips and ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of ConocoPhillips Australia Funding Company, ConocoPhillips Canada Funding Company I, and ConocoPhillips Canada Funding Company II, with respect to their publicly held debt securities. Similarly, ConocoPhillips has fully and unconditionally guaranteed the payment obligations of ConocoPhillips Company with respect to its publicly held debt securities. In addition, ConocoPhillips Company has fully and unconditionally guaranteed the payment obligations of ConocoPhillips with respect to its publicly held debt securities. All guarantees are joint and several. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for: ConocoPhillips, ConocoPhillips Company, ConocoPhillips Australia Funding Company, ConocoPhillips Canada Funding Company I, and ConocoPhillips Canada Funding Company II (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting). All other nonguarantor subsidiaries of ConocoPhillips. The consolidating adjustments necessary to present ConocoPhillips results on a consolidated basis. This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes. Millions of Dollars Three Months Ended June 30, 2009 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Australia Funding Company ConocoPhillips Canada Funding Company I ConocoPhillips Canada Funding Company II All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 21,922 - - - 13,526 - 35,448 Equity in earnings of affiliates 1,387 1,555 - - - 733 (2,599 ) 1,076 Other income (loss) 1 116 - - - (11 ) - 106 Intercompany revenues 15 220 12 19 12 3,969 (4,247 ) - Total Revenues and Other Income 1,403 23,813 12 19 12 18,217 (6,846 )